Method and system for power production with improved efficiency

ABSTRACT

The present disclosure relates to systems and methods that provide power generation using predominantly CO 2  as a working fluid. In particular, the present disclosure provides for the use of a portion of the heat of compression from a CO 2  compressor as the additive heating necessary to increase the overall efficiency of a power production system and method.

CROSS-REFERENCE TO RELATED APPLICATIONS

The present application claims priority to U.S. Provisional Patent Application No. 62/021,839, filed Jul. 8, 2014, the disclosure of which is incorporated herein by reference in its entirety.

FIELD OF THE DISCLOSURE

The presently disclosed subject matter relates to systems and methods for generation of power, such as electricity, that operate at desirable efficiencies that are achieved through additive heating of at least part of a recycle CO₂ stream in a heat exchanger using a further heat source. Particularly, heat from the further source can be derived at least in part from compression of at least a portion of the recycle CO₂ stream.

BACKGROUND

Conventional means of power production from combustion of a fuel typically lack the ability to simultaneously achieve high efficiency power generation and carbon capture (e.g., for sequestration or other use). One publication in the field of high efficiency power generation with carbon capture, U.S. Pat. No. 8,596,075 to Allam et al., provides for desirable efficiencies in closed cycle combustion systems using CO₂ as the working fluid. Such systems in particular benefit from the recognized usefulness of heating a recycle CO₂ stream in a recuperative heat exchanger using heat from the hot turbine exhaust as well as adding further heat from a source other than the turbine exhaust. Despite such advances, there is yet a growing need in the art for improved systems and methods for power generation that provide increased efficiency with capture of CO₂ and other fuel and combustion derived impurities.

SUMMARY OF THE DISCLOSURE

The present disclosure provides systems and methods of power production with improved efficiency. The systems and methods can utilize CO₂ as a working fluid and can be configured for capture of CO₂ and other fuel and combustion derived impurities. The present improvements have been identified in relation to the introduction of low temperature level heating to a recycle CO₂ stream in an elevated pressure, oxy-fuel combustion system and method that also utilizes recuperative heating of the recycle CO₂ stream with heat from the hot turbine exhaust. The low temperature level heating can be described herein in terms of being “additive heating.” As such, it is understood that the additive heating is low temperature level heat from a source other than the hot turbine exhaust. In other words, the additive heating is not heat that is recuperated from the hot turbine exhaust. The present disclosure in particular identifies means for obtaining and transferring the additive heating in a closed cycle or partially closed cycle oxy-fuel combustion system and method that provides a power production output that exceeds the heating capacity of the heat from the fuel alone and thus provides an advantageous increase in efficiency.

In some embodiments, the present disclosure relates to systems and methods for generation of power, such as electricity, that operate at desirable efficiencies that are achieved through the combustion of a fuel (e.g., a carbonaceous or carbonaceous fuel) in oxygen at elevated pressure in the presence of a recycle CO₂ stream followed by expansion of the product gas through a power producing turbine and cooling of the turbine exhaust in a recuperative heat exchanger, which heats the previously compressed recycle CO₂ stream. Improved efficiency of power generation can be obtained by additive heating of at least part of the recycle CO₂ stream in a heat exchanger using additive heating, which can be, for example, heat derived at least in part from compression of at least a portion of the recycle CO₂ stream.

In various embodiments, power production can be achieved utilizing a closed cycle or partially closed cycle system in which CO₂ is utilized as the working fluid. In such systems, a fossil fuel (e.g., natural gas) or a fuel derived from a fossil fuel (e.g., syngas derived from coal or other solid carbonaceous fuel) is completely combusted in a combustor using substantially pure oxygen as the oxidant to give an oxidized stream of predominantly CO₂, H₂O, excess O₂, and a quantity of impurities derived from oxidized components in the fuel or oxidant, such as SO₂, NO_(x), Hg, and HCl. Solid fossil fuels, such as coal, lignite, or petroleum coke, that contain non-combustible ash may be converted to a gaseous fuel by partial oxidation in a single stage or multi-stage system. Such system, for example, may comprise a partial oxidation reactor. Alternatively, for example, such system may comprise a partial oxidation reactor and an ash and volatile inorganic component removal system. Such systems further comprise combustion of the fuel gas with oxygen in the combustor of the power production system. A preheated recycle CO₂ stream is mixed in the combustor with the combustion products derived from combustion of the fuel gas. Any combustor adapted for operation under conditions otherwise described herein may be used, and the recycle CO₂ stream may be introduced to the combustor by any means to be further heated by the combustion and, if desired, to quench and thereby control the temperature of the exit stream. In some embodiments, one or both of a PDX reactor and the combustor may utilize, for purposes of example only, a transpiration cooled wall surrounding the reaction or combustion space, and the preheated recycle CO₂ stream may pass through the wall to both cool the wall and to quench and thereby control the temperature of the exit stream. The transpiration flow promotes good mixing between the recycle CO₂ and the hot combusted fuel gas streams. Other types of combustors, however, may also be used, and the present disclosure is not limited to the use of transpiration cooled combustors. Although certain fuel types are exemplified above, it is understood that other fuels (e.g., hydrogen) may be utilized in the combustor. Likewise, the advantages flowing from the use of additive heat may be applied to systems utilizing non-combustion heating in part or in total. For example, use of solar systems such as described in U.S. Pat. Pub. No. 2013/0118145, the disclosure of which is incorporated herein by reference, is also encompassed by the present disclosure.

The combined combustion products and preheated recycle CO₂ leaving the combustor are at the temperature required for the inlet to a power-producing turbine. The CO₂ power cycle can use a pressure ratio across the turbine from 5 to 12 in some embodiments, although greater pressure ratios (e.g. at least 20) may be used in other embodiments, such as when utilizing a plurality of expansion turbines. A turbine inlet pressure of about 100 bar (10 MPa) to about 500 bar (50 MPa) can be used in some embodiments. The oxygen supplied to the combustor can be either substantially pure O₂ or O₂ diluted with CO₂. In some embodiments, mixing of the O₂ and CO₂ can be useful to control the adiabatic flame temperature of the combustion reaction. As a non-limiting example, the molar concentration of O₂ in the combined O₂/CO₂ stream can be about 10% to about 50%, about 15% to about 40%, or about 20% to about 30%. The hot turbine exhaust can be cooled in an economizing heat exchanger, which in turn preheats the high pressure CO₂ recycle stream.

The efficient operation of the system is critically dependent on the optimization of the heat exchange. To achieve a high efficiency, a large quantity of additive heat can be added into the high pressure recycle stream at the cold end of the heat exchanger, such as at a temperature level from about 100° C. to about 400° C. This low temperature level heat may be derived in some embodiments from the air compressors of a cryogenic oxygen plant, which compressors may be operated wholly or in part with their pressure ranges in a high-pressure ratio adiabatic mode so that the compressed air is raised in temperature at the stage discharge to a point in the range of about 100° C. to about 400° C. and so that heat transfer from the compressed air stream to the pressurized recycle CO₂ process stream can be easily accomplished. For example, a side stream flow taken from the high pressure CO₂ recycle flow in the economizer heat exchanger can be heated against cooling compressed air to a required temperature of about 100° C. to about 400° C. Systems and methods for such oxyfuel combustion, low level heat production, and low level heat transfer are described in U.S. Pat. Nos. 8,596,075, 8,776,532, 8,986,002, 9,068,743, U.S. Pat. Pub. No. 2010/0300063, U.S. Pat. Pub. No. 2012/0067054, U.S. Pat. Pub. No. 2012/0237881, and U.S. Pat. Pub. No. 2013/0104525, the disclosures of which are incorporated herein by reference in their entireties.

The present disclosure provides further means for introducing heat into a recycle CO₂ high pressure stream at a temperature of about 100° C. to about 400° C. and thus increase the effectiveness of an economizer heat exchanger and increase the overall efficiency of the power production system and method incorporating the present heat transfer means. In particular, the present disclosure provides for the use of a portion of the heat of compression from a recycle CO₂ compressor as the additive heating necessary to increase the overall efficiency of a power production system and method.

Previous proposals have been made to optimize the performance of a power production cycle using high pressure CO₂ as the working fluid. For example, Bryant et al. (“An Analysis and Comparison of the Simple and Recompression Supercritical CO₂ Cycles” May 2011 presentation at the supercritical CO₂ power cycle workshop in Boulder, Colo.), the disclosure of which is incorporated herein by reference, describes Brayton cycles for power generation using recuperator heat exchanger with CO₂ as the working fluid. The paper defines the efficiencies of two cycles in terms of operating parameters and shows the conditions under which the second cycle gives a higher efficiency than the first, simple cycle.

The first, simple cycle from Bryant et al. is shown in FIG. 1. Therein, hot CO₂ in line 7 that has been compressed in a near adiabatic, non-intercooled compressor 1 is further heated in a recuperator heat exchanger 4. The hot CO₂ then passes through line 8 to the heater 3 where it is heated either directly by combusting a fuel 14 with oxygen 13, or by some means of external heating. The further heated CO₂ then passes through line 9 into a power producing turbine 2 where it is expanded to a lower pressure producing shaft work (illustrated by arrow 15). The turbine exhaust stream 10 passes to the recuperator heat exchanger 4 where it cools releasing heat to the high pressure recycle stream. The turbine exhaust is then cooled in a pre-cooler 5 where heat is rejected to a cooling stream 11 that exits via line 12 before finally re-entering the compressor 1 in line 6.

The second cycle from Bryant is shown in FIG. 2, which is identical to the cycle shown in FIG. 1 apart from the addition of a second compression stage 16 in which part of the low pressure turbine exhaust stream 17 leaving the low pressure return circuit at the exit from the recuperator heat exchanger 4 a before the pre-cooler 5 is compressed in its hot condition in compressor 16 leaving through line 18. This stream enters the recuperator heat exchanger 4 b after mixing with the main high pressure recycle stream leaving 4 a at its corresponding temperature and is heated in heat exchanger section 4 b against hot turbine exhaust stream 10. The effect of the additional compression is to inject a large amount of heat into the recuperator heat exchanger from the second compressor which takes as its inlet flow a CO₂ stream at an elevated temperature which is greater than the inlet temperature of the main CO₂ compressor.

The teaching of Bryant et al. reveals a disadvantage in that the heat input by-passes the first stage of the recuperator heat exchanger 4 a. The much larger specific heat of the high pressure CO₂ stream that is being heated in heat exchanger 4 a compared to the low pressure turbine exhaust stream cooling in heat exchanger 4 a means that the heat transfer in heat exchanger 4 a into the high pressure stream must be maximized to achieve a close temperature approach. This is not achieved since the heated compressed CO₂ stream bypasses heat exchanger 4 a. What is required for the maximum efficiency is to arrange a hot gas compression system in which the compressed CO₂ cools down in the heat exchanger and increases the available heat transfer to the high pressure CO₂ stream. The present disclosure relates in part to means for overcoming this disadvantage.

Although the cycles from Bryant et al. illustrated in FIG. 1 and FIG. 2 represent the known prior art for hot CO₂ compression, they are only suitable for use in simple Brayton cycle arrangements that use a main CO₂ compressor without intercoolers giving a high discharge temperature. This in turn causes the cooling turbine discharge flow leaving the recuperator heat exchanger 4 a to also be at a high temperature so the heat rejected in the pre-cooler heat exchanger is also high. It is therefore apparent that optimum efficiencies will only be achieved at low pressure ratios in this hot compression cycle which are shown to be in the range of 2 to 4 with optimum main compressor inlet pressures near the critical pressure of CO₂. Higher pressure ratios lead to excessive heat losses in the system. The Bryant et al. cycles shown in FIG. 1 and FIG. 2 also fail to account for system details such as the presence of liquid water separation in the compressor inlet lines 6 following cooling in the heat exchanger 5 against ambient cooling means.

The Bryant et al. cycle in FIG. 2 has several further limitations. For example, the Bryant et al. cycle efficiency significantly decreases as the pressure ratio is increased since the main and recompression compressors are essentially adiabatic in operation with no intercoolers between stages. The studies reported by Bryant et al. show that the optimum pressure ratio for a turbine inlet temperature of 750° C. is 2.2 at a turbine inlet pressure of 100 bar and 3.3 at a turbine inlet pressure of 250 bar. Low pressure ratios require very high CO₂ flow-rates in the system for a given power output leading to high capital costs. On the contrary, the present disclosure provides cycles with high pressure ratios and high turbine inlet pressures resulting in high efficiency and low capital cost.

Systems and methods useful according to the present disclosure can utilize pressure ratios of about 5 or greater, such as about 5 to about 30. In some embodiments, pressure ratios preferably can be in the range of about 5 to about 12. The present systems and methods also can utilize intercooled main CO₂ recycle compression systems. The high pressure ratio favors a turbine inlet pressure above the CO₂ critical pressure of 7.38 MPa and a turbine discharge pressure below this pressure. These higher pressure ratios give high efficiencies of 50% to 60% for natural gas fueled systems with significantly lower circulation rates of CO₂ per kW of net power output. Systems and methods useful according to the present disclosure also preferably utilize a very considerable input of additive heat at a temperature level of, for example, greater than 100° C., and particularly in the range of about 100° C. to about 400° C. or about 100° C. to about 300° C. The presently disclosed systems and methods are particularly beneficial in providing for utilization of a portion of the heat of compression from the main recycle CO₂ compressor as this additive heating.

In some embodiments, the present disclosure provides a method of generating power. For example, the method can comprise various combinations of the following steps: passing a compressed, heated recycle CO₂ stream into a combustor; combusting a fuel with oxygen in a combustor in the presence of the recycle CO₂ stream to produce a CO₂ containing stream; passing the CO₂ containing stream through a turbine to expand the CO₂ containing stream, generate power, and form a turbine exhaust stream comprising CO₂; withdrawing heat from the turbine exhaust stream comprising CO₂; dividing the cooled turbine exhaust stream to form a first turbine exhaust portion and second turbine exhaust portion; separating water from the first turbine exhaust portion to form a main recycle CO₂ stream; compressing the main recycle CO₂ stream; compressing the second turbine exhaust portion adiabatically with no intercooling between compressor stages to form a heated, compressed second turbine exhaust portion; withdrawing heat from the heated, compressed second turbine exhaust portion; separating water from the cooled, compressed second turbine exhaust portion to form a secondary recycle CO₂ stream; combining the main recycle CO₂ stream and the secondary recycle CO₂ stream to form a total recycle CO₂ stream; cooling the total recycle CO₂ stream to form a high density CO₂ stream; compressing the total recycle CO₂ stream in a second compression stage using a fluid pump; heating the total recycle CO₂ stream with heat withdrawn from the turbine exhaust stream; and further heating the total recycle CO₂ stream with heat withdrawn from the heated, compressed second turbine exhaust portion to form the compressed, heated recycle CO₂ stream. In some embodiments, the two compressed CO₂ streams following heat withdrawal from the secondary recycle CO₂ stream can be combined, then the combined stream can be cooled followed by liquid water separation. In some embodiments, the second turbine exhaust stream may be compressed in multiple stages with heat transfer between one or more of the stages. For example, the second turbine exhaust stream may undergo multi-stage compression including uncooled compression stages (x) and intercooled compression stages (y), wherein x and y independent may be an integer of 1 or more, 2 or more, or 3 or more (e.g., 1 to 5 or 2 to 4). In some embodiments, the second turbine exhaust stream may be pressurized (and heated) in x uncooled compression stage(s) to an intermediate value, the pressurized gas can be utilized to provide the heat of compression to a recuperative heat exchanger so as to be cooled, the cooled gas can be dewatered, and the gas can be passed back to undergo the remaining y intercooled compression stage(s) prior to joining with the first turbine exhaust stream.

In further embodiments, the present disclosure provides a power generating system. For example, the system can comprise: a combustor; a power production turbine; one or more heat exchangers; a first cooling flow path through the one or more heat exchangers; a heating flow path through the one or more heat exchangers; a flow separator in communication with the first cooling flow path through the one or more heat exchangers; a first compressor in communication with the flow separator; a second cooling flow path through the one or more heat exchangers, the second cooling flow path being in communication with the compressor; one or more water separators; a second compressor; and a pump. In particular, the heating flow path through the one or more heat exchangers is downstream from the pump and upstream from the combustor; and the heating flow path through the one or more heat exchangers is in a heating arrangement with the first cooling flow path and the second cooling flow path through the one or more heat exchangers. In some embodiments, the first cooling flow path and the second cooling flow path can be defined by separate and independent water separation components and/or pump components. When two or more heat exchangers are used, the heat exchangers may be in series.

In some embodiments, the present disclosure can relate to a method for heating a recirculating gas stream. As an example, such method can comprise the following steps: passing a gas stream G at a pressure P₁ and a temperature T₁ through a recuperative heat exchanger such that the gas stream is cooled to a temperature T₂ that is less than T₁; separating the gas stream G into a first fraction G₁ and a second fraction G₂; compressing the gas stream fraction G₁ to a pressure P₂ that is greater than P₁; compressing the gas stream fraction G₂ to a pressure P₃ that is greater than P₁ so as to heat the gas stream fraction G₂ to a temperature T₃ that is greater than T₂; withdrawing the heat from the compressed gas stream fraction G₂; combining the gas stream fraction G₁ and the gas stream fraction G₂ to form a combined recirculating gas stream G_(C); pumping the recirculating gas stream G_(C) to a pressure P₄ that is greater than P₂ and greater than P₃; and passing the recirculating gas stream G_(C) to the recuperative heat exchanger such that the gas stream G_(C) is heated by the cooling gas stream G; wherein the heat withdrawn from the compressed gas stream fraction G₂ is added to the recirculating gas stream G_(C) after pumping to pressure P₄. In further embodiments, the method for heating a recirculating gas stream may comprise any one or more of the following statements in any combination thereof.

The temperature T₃ can be about 100° C. to about 400° C.

The pressure P₂ of gas stream fraction G₁ and the pressure P₃ of gas stream fraction G₂ can each separately be about 40 bar (4 MPa) to about 100 bar (10 MPa).

The pressure P₄ of the recirculating gas stream G_(C) can be about 100 bar (10 MPa) to about 500 bar (50 MPa).

The mass ratio of gas fraction G₁ to gas fraction G₂ based on the total mass of gas stream G can be about 50:50 to about 99:1, or can be about 50:50 to about 90:10, or can be about 50:50 to about 70:30 or can be about 70:30 to about 90:10.

The recirculating gas stream G_(C) after passing through the recuperative heat exchanger and receiving the heat from the compressed gas fraction G₂ can have a temperature T₄ that is within 50° C. of T₁.

The gas stream fraction G₂ can be compressed with multi-stage compression with no intercooling.

After withdrawing heat from gas stream fraction G₂, the gas stream fraction G₂ can be further compressed before combining with gas stream fraction G₁.

The recuperative heat exchanger can comprise three heat exchangers or three heat exchange sections in series. In such embodiments, heat can be transferred in a first heat exchanger or heat exchange section operating in temperature range R₁, a second heat exchanger or heat exchange section operating in temperature range R₂, and a third heat exchanger or heat exchange section operating in temperature range R₃ with the temperature relationship of R₁>R₂>R₃.

The gas stream G can be separated between the first heat exchanger or heat exchange section and the second heat exchanger or heat exchange section.

The gas stream G can separated between the second heat exchanger or heat exchange section and the third heat exchanger or heat exchange section.

The heat withdrawn from the compressed gas stream fraction G₂ can be added to the recirculating gas stream G_(C) in one or both of the third heat exchanger or heat exchange section and the second heat exchanger or heat exchange section.

The method further can comprise adding heat to the recirculating gas stream G_(C) after pumping to pressure P₄. In such embodiments, the added heat can be derived from one or both of an air separation unit and a gas turbine.

The method further can comprise passing the heated recirculating gas stream G_(C) from the recuperative heat exchanger to a combustor that combusts a fuel with oxygen to form a combustion product stream.

The gas stream G can be a turbine exhaust stream.

In some embodiments, the present disclosure further can relate to a method of generating power. As an example, the method can comprise the following steps: combusting a fuel with oxygen in the combustor in the presence of a recycle CO₂ stream to produce a CO₂ containing combustion stream; passing the CO₂ containing combustion stream through a turbine to expand the CO₂ containing combustion stream, generate power, and form a turbine exhaust stream; withdrawing heat from the turbine exhaust stream; dividing the turbine exhaust stream to form a first turbine exhaust portion and second turbine exhaust portion; separating water from the first turbine exhaust portion to form a main recycle CO₂ stream; compressing the main recycle CO₂ stream; compressing the second turbine exhaust portion to form a heated, compressed second turbine exhaust portion; withdrawing heat from the heated, compressed second turbine exhaust portion; separating water from the cooled, compressed second turbine exhaust portion to form a secondary recycle CO₂ stream; combining the main recycle CO₂ stream and the secondary recycle CO₂ stream to form a combined recycle CO₂ stream; compressing the combined recycle CO₂ stream; heating the combined recycle CO₂ stream with heat withdrawn from the turbine exhaust stream; and further heating the combined recycle CO₂ stream with heat withdrawn from the heated, compressed second turbine exhaust portion. In further embodiments, the method can comprise one or more of the following statements in any combination.

The CO₂ containing combustion stream can have a temperature of about 500° C. to about 1,700° C. and a pressure of about 100 bar (10 MPa) to about 500 bar (50 MPa).

The pressure ratio across the turbine can be about 5 to about 12.

The heat can be withdrawn from the turbine exhaust stream in a recuperative heat exchanger comprising three or more sections or comprising three or more individual heat exchangers.

Heating the combined recycle CO₂ stream with heat withdrawn from the turbine exhaust stream and further heating the combined recycle CO₂ stream with heat withdrawn from the heated, compressed second turbine exhaust portion can be carried out in the recuperative heat exchanger.

The mass ratio of the first turbine exhaust portion to the second turbine exhaust portion based on the total mass of the turbine exhaust stream can be about 50:50 to about 99:1.

The heat withdrawn from the heated, compressed second turbine exhaust portion can be in a temperature range of about 100° C. to about 400° C.

The main recycle CO₂ stream and the second turbine exhaust portion can be independently compressed to a pressure of about 40 bar (4 MPa) to about 100 bar (10 MPa).

The combined recycle CO₂ stream after heating with heat withdrawn from the turbine exhaust stream and further heating with heat withdrawn from the heated, compressed second turbine exhaust portion can have a temperature that is within 50° C. of the temperature of the turbine exhaust stream.

The second turbine exhaust portion can be compressed adiabatically with no intercooling between compressor stages.

In some embodiments, a power generating system according to the present disclosure can comprise the following: a combustor configured to exhaust a combustion stream; a power production turbine configured to receive and expand the combustion stream and form a turbine exhaust stream; a recuperative heat exchanger configured to receive the turbine exhaust stream; a flow separator configured to separate the cooled turbine exhaust stream into a first gas stream and a second gas stream; a first compressor configured to receive and compress the first gas stream; a second compressor configured to receive and compress the second gas stream; a pump configured to pressurize the first gas stream and the second gas stream in combination, the pump positioned downstream from the first compressor and the second compressor; a first flow path through the recuperative heat exchanger configured for passage of the turbine exhaust stream; a second flow path through the recuperative heat exchanger configured for passage of the pressurized first gas stream and second gas stream in combination; a third flow path through the recuperative heat exchanger configured for passage of the compressed second gas stream; wherein the first flow path and the third flow path are configured for heating the second flow path. In further embodiments, the system can include any one or more of the following statements in any combination.

The recuperative heat exchanger can comprise a series of three or more heat exchangers or a series of three or more heating sections.

The system further can comprise one or more separators configured for separating at least water from one or both of the first gas stream and the second gas stream.

The first compressor can comprise a multi-stage, intercooled compressor.

The second compressor can comprise an adiabatic, multi-stage compressor with no intercooling between compressor stages.

BRIEF DESCRIPTION OF THE FIGURES

Having thus described the disclosure in the foregoing general terms, reference will now be made to the accompanying drawings, which are not necessarily drawn to scale, and wherein:

FIG. 1 is a flow diagram of a prior art power production cycle;

FIG. 2 is a flow diagram of a further prior art power production cycle; and

FIG. 3 is a flow diagram of a power production system and method according to an exemplary embodiment of the present disclosure including a plurality of compressors for compressing a recycle CO₂ stream and deriving heat therefrom for input to a recuperator heat exchanger.

DETAILED DESCRIPTION

The present subject matter will now be described more fully hereinafter with reference to exemplary embodiments thereof. These exemplary embodiments are described so that this disclosure will be thorough and complete, and will fully convey the scope of the subject matter to those skilled in the art. Indeed, the subject matter can be embodied in many different forms and should not be construed as limited to the embodiments set forth herein; rather, these embodiments are provided so that this disclosure will satisfy applicable legal requirements. As used in the specification, and in the appended claims, the singular forms “a”, “an”, “the”, include plural referents unless the context clearly dictates otherwise.

The present disclosure relates to systems and methods that provide power generation using predominantly CO₂ as a working fluid. In particular, the process uses a high pressure/low pressure ratio turbine that expands a mixture of a high pressure recycle CO₂ stream and combustion products arising from combustion of the fuel. Any fossil fuel, particularly carbonaceous fuels, may be used. Non-limiting examples include natural gas, compressed gases, fuel gases (e.g., comprising one or more of H₂, CO, CH₄, H₂S, and NH₃) and like combustible gases. Solid fuels—e.g., coal, lignite, petroleum coke, bitumen, biomass, and the like, or viscous liquid fuels may be used as well with incorporation of necessary system elements. For example, a partial oxidation combustor can be used to convert the solid or viscous liquid fuel to a fuel gas that is substantially free of solid particles. All fuel and combustion derived impurities in an oxidized state, such as sulfur compounds, NO, NO₂, CO₂, H₂O, Hg, and the like can be separated from the power cycle for disposal with substantially or completely no emissions to the atmosphere. As noted previously, other fuels likewise may be utilized. Pure oxygen can be used as the oxidant in the combustion process. In some embodiments, combustion temperature may be regulated by diluting the oxygen with CO₂ in ratios as otherwise noted herein.

The hot turbine exhaust is used to partially preheat the high pressure recycle CO₂ stream. In combination with this heating, the recycle CO₂ stream can be further heated using additive heating that can be derived from the compression energy of a CO₂ compressor. The operating conditions for the CO₂ compressor can vary as further described herein. For example, in some embodiments, it can be useful to utilize a CO₂ compressor inlet temperature that is higher than normal approach to ambient cooling means. The minimum inlet temperature of the stream entering the CO₂ compressor, for example, can be approximately the dew point of water at the operating conditions. In some embodiments, the CO₂ compressor can have an inlet temperature of about 50° C. to about 250° C. Optionally other heating means providing heat at a temperature level below about 400° C. can be used in addition to the heating available from the CO₂ compression. Such means can include heat transferred from the air compressors of a cryogenic air separation plant operating partially or completely in the adiabatic mode without intercooling. When such heat is utilized, the air compressors preferably can be operated with pressure ratios above 2.5 in the adiabatic stages.

It has been discovered according to the present disclosure that power production efficiency can be improved through provision of additive heating as defined herein, such additive heating particularly being provided at a temperature level below about 400° C. (e.g., in the range of about 100° C. to about 400° C.). The provision of the additive heating can overcome the large difference in the specific heat of CO₂ at a typical high pressure turbine inlet of about 300 bar (30 MPa) and the specific heat of CO₂ at a typical low pressure turbine exhaust pressure of about 30 bar (3 MPa). This difference is evident in the table provided below.

Temperature K CO₂ specific heat (kJ/kg) CO₂ specific heat (kJ/kg) (° C.) at 30 bar (3 MPa) at 300 bar (30 MPa) 300 (26.85)  1.18 1.95 350 (76.85)  1.05 2.00 400 (126.85) 1.02 1.90 450 (176.85) 1.03 1.63 500 (226.85) 1.06 1.47 600 (326.85) 1.10 1.31 750 (476.85) 1.17 1.23 1000 (726.85)  1.24 1.28

A power production method according to the present disclosure particularly can comprise a series of steps that can provide for improved efficiency. The method can comprise passing a compressed, heated recycle CO₂ stream into a combustor. The compressed, heated recycle CO₂ stream can be formed as further described below. In the combustor, a fuel can be combusted with the oxidant (e.g., oxygen of at least 98% or at least 99% purity, optionally diluted with CO₂) in the presence of the recycle CO₂ stream to produce a CO₂ containing stream. The CO₂ containing stream from the combustor can have a temperature of about 500° C. or greater (e.g., about 500° C. to about 1,700° C. or about 800° C. to about 1,600° C.) and a pressure of about 100 bar (10 MPa) or greater (e.g., about 100 bar (10 MPa) to about 500 bar (50 MPa)). The CO₂ containing stream can be passed through a turbine to expand the CO₂ containing stream, generate power, and form a turbine exhaust stream comprising CO₂. The CO₂ containing stream can be expanded across the turbine at a pressure ratio of less than 12 or less than 10 (e.g., about 5 to about 12). In alternate embodiments, high pressure ratios as noted herein may be used, such as in the case of utilizing a plurality of turbines, as described in U.S. Pat. Pub. No. 2013/0213049, the disclosure of which is incorporated herein by reference in its entirety.

The turbine exhaust stream can be processed to remove combustion products and any net CO₂ produced by combustion of the fuel. To this end, the turbine exhaust stream can be cooled by passage through a heat exchanger. Any heat exchanger suitable for use under the temperature and pressure conditions described herein can be utilized. In some embodiments, the heat exchanger can comprise a series of at least two, at least three, or even more economizer heat exchangers. A single heat exchanger with at least two sections, at least three sections (or even more sections) can be used. For example, the heat exchanger may be described has having at least three heat exchange sections operating across different temperature ranges. Withdrawn heat from the turbine exhaust stream can be utilized for heating the recycle CO₂ stream as described below.

The turbine exhaust stream can be divided into two or more portions. The first portion can comprise 50% or greater, 70% or greater, or 90% or greater (but less than 100%) of the total mass flow of the turbine exhaust stream. The first turbine exhaust portion is cooled preferably at a temperature that is less than the water dew point after leaving the heat exchanger. The first turbine exhaust portion can be passed through a separator to remove water and can be further treated to remove other combustion products or impurities. The resulting stream can be described as a main recycle CO₂ stream, and this stream can be compressed such as in a multi-stage compressor with intercooling between the stages. Preferably, the main recycle CO₂ stream is compressed to a pressure of about 40 bar (4 MPa) to about 100 bar (10 MPa). In some embodiments, the main recycle CO₂ stream is compressed to a pressure of about 60 bar (6 MPa) to about 100 bar (10 MPa) or about 67 bar (6.7 MPa) to about 80 bat (8 MPa).

The second portion of the turbine exhaust stream can be compressed to form a heated, compressed second turbine exhaust portion. The second turbine exhaust portion can comprise the balance of the turbine exhaust not present in the first portion (e.g., 50% or less, 30% or less, or 10% or less (but greater than 0%) of the total mass flow of the turbine exhaust stream). Preferably, the second turbine exhaust portion can be withdrawn from the turbine exhaust between the second and third heat exchange sections (e.g., the second and third heat exchangers in the series moving from hot to cold—in other words, the heat exchangers working between the lowest temperature and an intermediate temperature). The second turbine exhaust portion is preferably compressed so as to achieve a temperature in the range of about 100° C. to about 400° C. and a pressure of about 40 bar (4 MPa) to about 100 bar (10 MPa). In some embodiments, the pressure can be about 60 bar (6 MPa) to about 100 bar (10 MPa) or about 67 bat (6.7 MPa) to about 80 bar (8 MPa). The second turbine exhaust portion can be re-introduced to the heat exchanger, preferably passing from the hot end of the intermediate temperature heat exchanger to the cold end of the low temperature heat exchanger. The cooled second turbine exhaust portion can be at a temperature that is below the water dew point, and the cooled stream can be passed through one or more separators to remove water and any other impurities. The remaining stream is a secondary recycle CO₂ stream, and it can be combined with the main recycle CO₂ stream. Such combining can be at a variety of points. For example, the main recycle CO₂ stream can be added to the cooled second portion of the turbine exhaust after passage through the low temperature heat exchanger and before passage through the separator. Alternatively, the main recycle CO₂ stream and the secondary recycle CO₂ stream can be combined after water separation or at another point of the cycle. Net CO₂ produced from combustion can be withdrawn at this point, such as for use in enhanced oil recovery, for sequestration, or the like.

In some embodiments, the second turbine exhaust portion can be compressed using multi-stage compression wherein there is no inter-cooling between stages followed by inter-cooling between later stages. Compressed and heated gas of the second turbine exhaust portion exiting the non-cooled stages can be introduced to the heat exchanger as otherwise described above, and the so-cooled stream can be subjected to the inter-cooled compression before combining with the first turbine exhaust portion. The number of non-cooled stages (x) and inter-cooled stages (y) can independently be 1 or more, 2 or more, or 3 or more (e.g., 1 to 5 or 2 to 4).

The total recycle CO₂ stream (formed of the main recycle CO₂ stream and the secondary recycle CO₂ stream) can be pumped to a pressure suitable for passage into the combustor. Preferably, the total recycle CO₂ stream is pumped to a pressure of at 100 bar (10 MPa) or greater or about 200 bar (20 MPa) or greater, such as about 100 bar (10 MPa) to about 500 bar (50 MPa). The compressed recycle CO₂ stream is then passed back through the heat exchangers to be heated. The compressed recycle CO₂ stream is heated using the heat withdrawn from the turbine exhaust stream (which can be characterized as the heat of combustion that remains in the turbine exhaust stream). The heat in the turbine exhaust stream, however, is insufficient to achieve a close temperature approach between the turbine exhaust stream and the heated, compressed recycle CO₂ stream at the hot end of the heat exchanger. According to the present disclosure, the heat from the compressed, second turbine exhaust portion can be used as additive heating to reduce the temperature differential between the turbine exhaust stream and the heated, compressed recycle CO₂ stream leaving the heat exchanger and entering the combustor. The additive heating can be characterized as the heat of recompression and is separate from the heat of combustion that is present in the turbine exhaust. The use of the additive heating can be beneficial to reduce temperature differential between the turbine exhaust stream and the heated, compressed recycle CO₂ stream leaving the heat exchanger and entering the combustor to about 50° C. or less, about 40° C. or less, or about 30° C. or less, such as about 10° C. to about 50° C., or about 20° C. to about 40° C.

In some embodiments, additive heating can be provided by other means in combination with or as an alternative to the heat of recompression. For example, heated CO₂ from an external source can be utilized. Such external source can be, for example, CO₂ withdrawn from a geological source, CO₂ taken from a pipeline, or the like. In such embodiments, splitting of the turbine exhaust stream can be unnecessary, and the heated CO₂ can be input to the system in the same manner as the heat of recompression described above. The additional CO₂ can be withdrawn from the system with the net CO₂ product and can be returned to the heat source. In such manner, a recycled CO₂ from an external source completely outside of the power production system can be utilized as additive heating. Alternatively, part or all of the additive heating can be from a gas turbine exhaust or from a condensing stream.

An exemplary embodiment of a system according to the present disclosure is shown in FIG. 3. The embodiment is described in relation to an exemplary embodiment of a combustion method utilizing defined parameters. Specific temperatures and pressures thus can vary based upon the specific operation conditions.

In the embodiment of FIG. 3, a turbine exhaust stream 55 at 728° C. and 30 bar (3 MPa) passes through three economizer heat exchangers in series 29, 27, and 26 leaving as stream 46 at 46° C. and 29 bar (2.9 MPa). Heat exchanger 29 may be characterized as a high temperature heat exchanger, heat exchanger 27 may be characterized as an intermediate temperature heat exchanger, and heat exchanger 26 may be characterized as a low temperature heat exchanger. It is understood that the terms “high temperature,” “intermediate temperature,” and “low temperature,” are intended to only describe the operating temperature ranges of the three heat exchangers relative to one another. The stream 46 is cooled in a water cooled heat exchanger 58 to 17.2° C., and a condensed water stream 56 is separated in the phase separator vessel 53. An overhead CO₂ gas stream 61 leaves the phase separator vessel 53 and enters a two stage centrifugal CO₂ recycle compressor 21 (stage 1) and 22 (stage 2), wherein a discharge stream 44 from the first stage compressor 21 is cooled in an intercooler 23 to 17.2° C., exits as stream 45, and is then compressed in the second stage compressor 22 to form stream 48 at 80 bar (8 MPa). This main recycle compressor discharge stream 48 joins with stream 47, and the combined stream 69 is cooled in a water cooled heat exchanger 24 to a temperature of 22.7° C. In other embodiments, this temperature can be in the range of 10° C. to about 30° C. Condensed water 68 is separated in a phase separator 67 producing the total recycle CO₂ stream 49, which is in the supercritical state and has a high density of 850 Kg/m³. A net product CO₂ stream 62, equivalent to the carbon in the fuel gas converted to CO₂ in the combustor, is removed from the system (after cooling, as illustrated, or before cooling) for sequestration, use in enhanced oil recovery, or the like.

The total recycle CO₂ stream 49 is cooled in heat exchanger 70 to a temperature of 17.2° C. then enters a multi-stage centrifugal pump 25 with a discharge pressure of 305 bar (30.5 MPa) to from a high pressure CO₂ recycle stream 50, which is heated in the three economizer heat exchangers in series 26, 27 and 29 leaving as stream 54 at a temperature of 725° C. and 302 bar (30.2 MPa). The stream 54 is heated to 1154° C. in combustor 30 by the direct combustion of a natural gas stream 40 with a 99.5% O₂ stream 41, both at 320 bar (32 MPa). In the exemplified embodiment, modeling was done with pure CH₄ as the fuel gas. The mixed stream of recycle CO₂ and combustion products 57 enters a power turbine 31 with a discharge pressure of 30 bar (3 MPa) and exits as turbine exhaust stream 55.

As seen in the table above, the difference in the specific heat of CO₂ at 300 bar (30 MPa) and 30 bar (3 MPa) increases as the temperature drops from 1000 K (727° C.). In light of this difference, additive heating is required to achieve a very close temperature approach between the turbine exhaust stream 55 and the recycle CO₂ stream 54, and such additive heating can be supplied, for example, in the “low temperature” economizer heat exchanger 26 and/or the “intermediate temperature” economizer heat exchanger 27. According to the present disclosure, the additive heating can be provided by utilizing the adiabatic heat of compression of part of the recycle CO₂ stream which, in the exemplary embodiment, is compressed to a pressure of about 29 bar (2.9 MPa) to about 80 bar (8 MPa).

Returning to the exemplary embodiment of FIG. 3, a portion of the cooling turbine exhaust stream 51 between the two economizer heat exchanger sections 27 and 26 at a temperature of 138° C. can be withdrawn and compressed in a single stage or multi-stage adiabatic compressor 28 producing stream 52 at 246° C. and 80 bar (8 MPa). The compressed and heated stream 52 re-enters the hot end of economizer heat exchanger 27, and the stream is passed through heat exchanger 27 and heat exchanger 26 where it cools and leaves as stream 47 at 54° C. The entire heat of compression in compressor 28 supplied by work stream 34 is thusly transferred to the high pressure recycle CO₂ stream, and this heat input is equivalent to heat of combustion delivered in the combustor 30 since it reduces the hot end temperature difference. The flow-rate of stream 51 is maximized to achieve a significantly small temperature difference between streams 65 and 66 at the inlet to the high temperature economizer heat exchanger 29. This temperature difference between streams 65 and 66 preferably is about 50° C. or less, about 40° C. or less, about 30° C. or less, about 20° C. or less, particularly about 10° C. to about 50° C., or about 20° C. to about 40° C. As discussed above, stream 47 joins with the main recycle compressor discharge stream 48 for cooling in heat exchanger 24 to 22.7° C. The additive heating provide by CO₂ compression as described above provides for increased efficiency in the power production system.

Note that other sources of low temperature level heating (e.g., gas turbine exhaust or condensing stream) can be utilized as the additive heating. The exemplary embodiment of FIG. 3 includes the cryogenic air separation plant 81 main air flow 42 a which has been adiabatically compressed to 5.7 bar (0.57 MPa) and 223° C. entering the hot end of economizer heat exchanger 27 as stream 42 and leaving heat exchanger 26 as stream 43 at 54° C. In some embodiments, stream 42 may arise from stream 42 b, which is illustrated as heat derived from a gas turbine 83. Although not illustrated in FIG. 3, in some embodiments, the O₂ stream can be supplied from the air separation plant at 80 bar (8 MPa) and ambient temperature and can be mixed with CO₂ from stream 49 to give 25 mol % O₂ that can be compressed to 320 bar (32 MPa) before being heated to 725° C. in the economizer heat exchangers 27, 26 and 29. In practice, this CO₂+O₂ compressor can also feature a hot gas compressor section as has been shown for the CO₂ recycle compressor. In FIG. 3, cooling water inlet streams are represented as streams 38, 59, 72, and 36, while the respective outlet streams are represented as streams 39, 60, 74, and 37. The compressor power inputs are illustrated in FIG. 3 as elements 32 and 34, and such power inputs may be electric or may be turbine driven. The CO₂ pump electric power input is illustrated as element 33. The turbine shaft power output is illustrated as element 64 from the generator 63.

The exemplary embodiment described was evaluated with ASPEN modeling software using actual machine efficiencies, heat exchanger temperature differences, and system pressure drops giving a net efficiency of 58.5% (LHV basis). The calculation was based on a thermal input of 500 MW to the combustor 30.

Although the disclosed systems and methods may be particularly applicable to combustion systems and methods for power production, a broader application to efficient heating of a gas stream is also encompassed. As such, in some embodiments, the present disclosure can relate to a method for heating a gas stream, and particularly for heating a recirculating gas stream. The recirculating gas stream may be any gas stream that is continuously cycle through stages of heating and cooling, optionally including stages of compression and expansion.

A gas stream G that may be subject to heating according to the present disclosure may be any gas; however, it can be particularly advantageous for the gas stream G to comprise CO₂, such as being at least about 10%, at least about 25%, at least about 50%, at least about 75%, or at least about 90% by mass CO₂. A recirculating gas stream G particularly may be at increased temperature T₁ (e.g., about 500° C. to about 1700° C.) and a pressure P₁ that enables forming a desired amount of heat of compression—e.g., a pressure of less than about 40 bar (4 MPa). The gas stream G at pressure P₁ and temperature T₁ can be cooled, such as by passage through a recuperative heat exchanger. Preferably, cooling is such that the gas stream G is cooled to a temperature T₂ that is less than T₁. In some embodiments, cooling can be carried out using a series of multiple heat exchangers (e.g., 2, 3, or more heat exchangers) or using a heat exchanger that includes a plurality of heat exchange sections or using a combination thereof. The individual heat exchangers (or heat exchange sections) can exchange heat at different temperature ranges, which ranges may overlap. Use of multiple heat exchangers and/or heat exchange sections enables streams to be added or withdrawn at different temperature ranges.

The gas stream G can be separated into a first fraction G₁ and a second fraction G₂. Such separation can occur after the gas stream G has been cooled to the temperature T₂ or to an intermediate temperature T_(int) that is between T₁ and T₂. The temperature T₂, for example, can be the temperature at the cold end of the recuperative heat exchanger (or the heat exchanger or heat exchange section working over the lowest temperature range), and the temperature T_(int), for example, can be a temperature at the cold end of a second heat exchanger (or second heat exchange section) in a series of three or more heat exchangers (or heat exchange sections). Preferably, the second gas fraction G₂ can be withdrawn at an intermediate temperature prior to further cooling of the first gas fraction G₁. After the gas stream fraction G₁ has been cooled, it can then be compressed to a greater pressure P₂ that preferably can be greater than P₁. Such compression, for example, can be carried out with a multi-stage compressor that is intercooled. The pressure P₃ can be, for example, about 40 bar (4 MPa) to about 100 bar (10 MPa), about 60 bar (6 MPa) to about 100 bar (10 MPa) or about 67 bar (6.7 MPa) to about 80 bat (8 MPa).

The withdrawn gas stream fraction G₂ can be separately compressed to a pressure P₃ that also preferably is greater than P₁. The pressure P₃ can be in the same range of pressure P₂; however, P₂ and P₃ do not necessarily need to be identical. In some embodiments, the gas stream fraction G₂ can be compressed using adiabatic compression with no intercooling so as to heat the gas stream fraction G₂ to a temperature T₃ that is greater than T₂. In embodiments wherein the gas stream fraction G₂ can be withdrawn at the intermediate temperature T_(int), T₃ preferably is greater than T_(int). The heat from the compressed gas stream fraction G₂ can be withdrawn and used as additive heating to the recirculating gas stream as further described below.

After the compression heat has been withdrawn from gas stream fraction Ga, the gas stream fraction G₁ and the gas stream fraction G₂ can be combined to form a combined recirculating gas stream G_(C). The recirculating gas stream G_(C) will have a pressure that is substantially similar to the pressure P₂ and/or P₃ and can be pumped to a greater pressure P₄ that is greater than P₂ and greater than P₃. Such pumping is desirable is the recirculating gas stream G_(C) is being utilized in a high pressure application. In some embodiments, however, the pressure P₂ and/or P₃ may be suitable and no further compression may be required.

The recirculating gas stream G_(C) (optionally at the pressure P₄) can be passed to the recuperative heat exchanger such that the gas stream G_(C) is heated by the cooling gas stream G. The heat withdrawn from the compressed gas stream fraction G₂ can be added to the recirculating gas stream G_(C). Such additive heating can be carried out after pumping to pressure P₄. In some embodiments, the additive heating can be carried out in the recuperative heat exchanger. For example, if a single recuperative heat exchanger is used, the heat of compressed gas stream fraction G₂ can be input to the heat exchanger at a suitable point to provide the additive heating to the recirculating gas stream G_(C) in the desired temperature range. In embodiments wherein a plurality of heat exchanger (or heat exchange sections) are used, the heat of compressed gas stream fraction G₂ can be added to one or more of the lower temperature heat exchangers (or heat exchange sections). For example, during compression, gas stream fraction G₂ can be heated to a temperature in the range of about 100° C. to about 400° C., and the heat from the compressed gas stream fraction G₂ can be added to one or more heat exchangers (or heat exchange sections) working in this temperature range. In FIG. 3, for example, compressed gas stream fraction G₂ would equate to stream 52, which is passed through heat exchangers 26 and 27, which are working at a lower temperature range than heat exchanger 29. Generally, a series of heat exchangers such as illustrated in FIG. 3, comprises three heat exchangers that each transfer in separate temperature ranges (which ranges may overlap). In the example of FIG. 3, heat exchanger 29 can be characterized as operating in a temperature range R₁, heat exchanger 27 can be characterized as operating in a temperature range R₂, and heat exchanger 26 can be characterized as operating in a temperature range R₃. As illustrated, since heat exchanger 29 is at the hot end of the series and heat exchanger 26 is at the cold end of the series, the temperature relationship of the series of heat exchangers would be R₁>R₂>R₃.

The use of the additive heating provided by the compression heat in compressed gas stream fraction G₂ can be beneficial to bring the temperature of the combined recirculating gas stream G_(C) significantly close to the temperature of gas stream G prior to cooling. For example, the recirculating gas stream G_(C) after passing through the recuperative heat exchanger and receiving the heat from the compressed gas fraction G₂ can have a temperature T₄ that is within 50° C. of T₁. Typically, the temperature T₄ of recirculating gas stream G_(C) after passing through the recuperative heat exchanger will remain below T₁. In such embodiments, recirculating gas stream G_(C) after passing through the recuperative heat exchanger and receiving the heat from the compressed gas fraction G₂ can have a temperature T₄ that is less than T₁ by no more than 50° C.

The approach of T4 to T1 can be further improved through addition of heat from one or more additional sources. Such additional heat source can comprise any device or combination of devices configured to impart heating to a stream that is sufficient to heat a gas stream as described herein so that the gas stream achieves the desired quality and quantity of heat. As non-limiting examples, the additional heat source can be one or more of a combustion heat source, a solar heat source, a nuclear heat source, a geothermal heat source, and an industrial waste heat source. The additional heat source may include a heat exchanger, a heat pump, a power producing device, and any further combination of elements (e.g., piping and the like) suitable to form, provide, or deliver the necessary heat.

The method for heating a recirculating gas stream can further comprise one or more steps. For example, the gas stream G may be a stream exiting a turbine. As such, the pressure P₁ of gas stream G can be less than an earlier pressure P₀ of the gas stream before passage through the turbine. In some embodiments, P₀ can be substantially similar to P₄ (e.g., within 10%, within 5%, or within 2% thereof). In some embodiments, recirculating gas stream G_(C) can be subjected to a superheating step after exiting the hot end of the heat exchanger (i.e., after being re-heated in the heat exchanger and receiving the additive heat of compression from G₂). For example, recirculating gas stream G_(C) can be heated with heat of combustion, with solar heating, with nuclear heating, with geothermal heating, with industrial waste heating, or with any combination thereof. In some embodiments, recirculating gas stream G_(C) can be so-heated and then passed through a turbine for expansion and power production. The stream leaving the turbine may then be characterized again as gas stream G.

Many modifications and other embodiments of the presently disclosed subject matter will come to mind to one skilled in the art to which this subject matter pertains having the benefit of the teachings presented in the foregoing descriptions and the associated drawings. Therefore, it is to be understood that the present disclosure is not to be limited to the specific embodiments described herein and that modifications and other embodiments are intended to be included within the scope of the appended claims. Although specific terms are employed herein, they are used in a generic and descriptive sense only and not for purposes of limitation. 

1. A method for heating a recirculating gas stream comprising: passing a gas stream G at a pressure P₁ and a temperature T₁ through a recuperative heat exchanger such that the gas stream is cooled to a temperature T₂ that is less than T₁; separating the gas stream G into a first fraction G₁ and a second fraction G₂; compressing the gas stream fraction G₁ to a pressure P₂ that is greater than P₁; compressing the gas stream fraction G₂ to a pressure P₃ that is greater than P₁ so as to heat the gas stream fraction G₂ to a temperature T₃ that is greater than T₂; withdrawing the heat from the compressed gas stream fraction G₂; combining the gas stream fraction G₁ and the gas stream fraction G₂ to form a combined recirculating gas stream G_(C); pumping the recirculating gas stream G_(C) to a pressure P₄ that is greater than P₂ and greater than P₃; and passing the recirculating gas stream G_(C) to the recuperative heat exchanger such that the gas stream G_(C) is heated by the cooling gas stream G; wherein the heat withdrawn from the compressed gas stream fraction G₂ is added to the recirculating gas stream G_(C) after pumping to pressure P₄.
 2. The method according to claim 1, wherein the temperature T₃ is about 100° C. to about 400° C.
 3. The method according to claim 1, wherein the pressure P₂ of gas stream fraction G₁ and the pressure P₃ of gas stream fraction G₂ are each separately about 40 bar (4 MPa) to about 100 bar (10 MPa).
 4. The method according to claim 1, wherein the pressure P₄ of the recirculating gas stream G_(C) is about 100 bar (10 MPa) to about 500 bar (50 MPa).
 5. The method according to claim 1, wherein the mass ratio of gas fraction G₁ to gas fraction G₂ based on the total mass of gas stream G is about 50:50 to about 99:1.
 6. The method according to claim 1, wherein the recirculating gas stream G_(C) after passing through the recuperative heat exchanger and receiving the heat from the compressed gas fraction G₂ has a temperature T₄ that is within 50° C. of T₁.
 7. The method according to claim 1, wherein gas stream fraction G₂ is compressed with multi-stage compression with no intercooling.
 8. The method according to claim 1, wherein after withdrawing heat from gas stream fraction G₂, the gas stream fraction G₂ is further compressed before combining with gas stream fraction G₁.
 9. The method according to claim 1, wherein the recuperative heat exchanger comprises three heat exchangers or three heat exchange sections in series, such that heat is transferred in a first heat exchanger or heat exchange section operating in temperature range R₁, a second heat exchanger or heat exchange section operating in temperature range R₂, and a third heat exchanger or heat exchange section operating in temperature range R₃ with the temperature relationship of R₁>R₂>R₃.
 10. The method according to claim 9, wherein the gas stream G is separated between the first heat exchanger or heat exchange section and the second heat exchanger or heat exchange section.
 11. The method according to claim 9, wherein the gas stream G is separated between the second heat exchanger or heat exchange section and the third heat exchanger or heat exchange section.
 12. The method according to claim 9, wherein the heat withdrawn from the compressed gas stream fraction G₂ is added to the recirculating gas stream G_(C) in one or both of the third heat exchanger or heat exchange section and the second heat exchanger or heat exchange section.
 13. The method according to claim 1, further comprising adding heat to the recirculating gas stream G_(C) after pumping to pressure P₄, wherein the added heat is derived from one or both of an air separation unit and a gas turbine.
 14. The method according to claim 1, further comprising passing the heated recirculating gas stream G_(C) from the recuperative heat exchanger to a combustor that combusts a fuel with oxygen to form a combustion product stream.
 15. The method according to claim 1, wherein the gas stream G is a turbine exhaust stream.
 16. A method of generating power, the method comprising: combusting a fuel with oxygen in the combustor in the presence of a recycle CO₂ stream to produce a CO₂ containing combustion stream; passing the CO₂ containing combustion stream through a turbine to expand the CO₂ containing combustion stream, generate power, and form a turbine exhaust stream; withdrawing heat from the turbine exhaust stream; dividing the turbine exhaust stream to form a first turbine exhaust portion and second turbine exhaust portion; separating water from the first turbine exhaust portion to form a main recycle CO₂ stream; compressing the main recycle CO₂ stream; compressing the second turbine exhaust portion to form a heated, compressed second turbine exhaust portion; withdrawing heat from the heated, compressed second turbine exhaust portion; separating water from the cooled, compressed second turbine exhaust portion to form a secondary recycle CO₂ stream; combining the main recycle CO₂ stream and the secondary recycle CO₂ stream to form a combined recycle CO₂ stream; compressing the combined recycle CO₂ stream; heating the combined recycle CO₂ stream with heat withdrawn from the turbine exhaust stream; and further heating the combined recycle CO₂ stream with heat withdrawn from the heated, compressed second turbine exhaust portion. 17-25. (canceled)
 26. A power generating system comprising: a combustor configured to exhaust a combustion stream; a power production turbine configured to receive and expand the combustion stream and form a turbine exhaust stream; a recuperative heat exchanger configured to receive the turbine exhaust stream; a flow separator configured to separate the cooled turbine exhaust stream into a first gas stream and a second gas stream; a first compressor configured to receive and compress the first gas stream; a second compressor configured to receive and compress the second gas stream; a pump configured to pressurize the first gas stream and the second gas stream in combination, the pump positioned downstream from the first compressor and the second compressor; a first flow path through the recuperative heat exchanger configured for passage of the turbine exhaust stream; a second flow path through the recuperative heat exchanger configured for passage of the pressurized first gas stream and second gas stream in combination; a third flow path through the recuperative heat exchanger configured for passage of the compressed second gas stream; wherein the first flow path and the third flow path are configured for heating the second flow path.
 27. The power generating system according to claim 26, wherein the recuperative heat exchanger comprises a series of three or more heat exchangers or a series of three or more heating sections.
 28. (canceled)
 29. The power generating system according to claim 26, wherein the first compressor comprises a multi-stage, intercooled compressor.
 30. The power generating system according to claim 26, wherein the second compressor comprises an adiabatic, multi-stage compressor with no intercooling between compressor stages. 